Transmission Protection Overview

Transcription

1 Transmission Protection Overview 2012 Hands-On Relay School Brian Smyth Schweitzer Engineering Laboratories Pullman, WA

2 Transmission Line Protection Objective General knowledge and familiarity with transmission protection schemes

3 Transmission Line Protection Topics Primary/backup protection Coordination Communication-based schemes Breaker failure protection Out-of-step relaying Synchronism checking

4 Primary Protection Function Trip for abnormal system conditions that may Endanger human life Damage system equipment Cause system instability

5 Protection Zones Primary protection first line of defense Backup protection operates when primary fails

6 How Can A Protection System Fail? Current or voltage signal supply Tripping voltage supply Power supply to the relay Protective relay Tripping circuit Circuit breaker

7 Two Types of Backup Remote backup Located at different station No common elements Local backup Located at same station Few common elements Separate relays Independent tripping supply and circuit Different current and voltage inputs

8 Remote vs Local Backup Speed Remote is slower Selectivity Remote disconnects larger part of the system Price Local requires additional equipment

9 Primary and Backup Coordination Best selectivity with minimum operating time Achieved through settings Pick up values Time delays

10 Coordination Types Considered Time-Overcurrent Time-Stepped Distance Communication-Aided Schemes

11 Time-Overcurrent Relays Definite-Time Overcurrent Operate in a settable time delay when the current exceeds the pickup value Instantaneous operation no intentional time delay Inverse-Time Overcurrent Operating curve defined by limiting the total fault energy (K d = I 2 t)

12 Time-Overcurrent Coordination Inverse-Time Overcurrent Pickup of relay A set low enough to see the fault shown and backup relay C Pickup should be above emergency load conditions (phase relays) Time delay of relay A should allow relay C to clear the fault first

13 Time-Overcurrent Coordination S - Selectivity time delay (aka CTI): Breaker operating time Overtravel (impulse) time (E/M relays) Safety margin 0.2s CTI 0.4s

14 Time-Overcurrent Coordination Looped Systems Directionality required for most relays a-b-c-d-e Relays at 5 and e can be nondirectional

15 Instantaneous Overcurrent Protection Inverse-Time O/C coordination may result in long time delays Instantaneous O/C relays set to trip for faults for ~80% of the line section Significantly reduced tripping times for many faults

16 Time-Stepped Distance Protection Coordination similar to that of inverse-time O/C Relay at A set to trip instantaneous for faults in its Zone 1 (reaching ~80% of the line section) Relay at A backs up relay at C after Zone 2 timer times out Faults at the end of the line also cleared in Zone 2 time

17 Communication-Based Protection Rationale Distance protection can clear faults instantaneously for 60% to 80% of the line length Protection speed may be critical to maintain system stability High-speed autoreclosing application

18 Communication-Based Protection Communication Mediums Power Line Carrier Microwave Fiber-Optics Private and Leased Pilot Channels

19 Communication-Based Protection Scheme Types Permissive Overreaching Transfer Trip (POTT) Permissive Underreaching Transfer Trip (PUTT) Directional Comparison Blocking (DCB) Directional Comparison Unblocking (DCUB) Direct Underreaching Transfer Trip (DUTT) Direct Transfer Trip (DTT)

20 Permissive Overreaching TT Protective Zones

21 Permissive Overreaching TT Permissive signal must be detected from the remote end for the communicationaided trip Absence of communication channel disables the accelerated tripping

22 Permissive Overreaching TT Complications and Concerns Desensitization due to infeed Dependability issue failure to trip high speed Current reversal Occurs in parallel lines with sequential tripping Security issue coupled with long channel reset times may cause trip of the healthy parallel line

23 Current Reversal All Sources In Z2 at Breaker 1 picks up and sends permissive signal to Breaker 2 Z2 at Breakers 3 and 4 send permissive signals to each other Z1 at Breaker 4 trips instantaneously

24 Current Reversal System After Breaker 4 Opens Current reverses through the healthy line Z2 at Breaker 2 picks up If the permissive signal has not reset, Breaker 2 trips on POTT

25 Current Reversal Possible Solution Timer with instantaneous pickup and time delayed dropout, initiated on reverse Z3 Delay trip with POTT until the timer drops out

26 Permissive Underreaching TT Similar to POTT but permissive signal sent by underreaching Z1 elements At the receiving end, Z2 elements qualify the permissive signal No problems with current reversal since Z1 doesn t overreach

27 Directional Comparison Blocking Protective Zones Zone 2 elements cover the entire line Reverse Zone 3 elements must reach further than the opposite Zone 2 overreach

28 Directional Comparison Blocking Basic Logic In-section faults will not key transmitter and both ends trip high-speed Out-of-section fault will key the transmitter at the nearest end to block the trip at the opposite end

29 Directional Comparison Blocking Complications and Concerns Coordinating time at fault inception Z3 faster than Z2, but channel delay time reduces the margin Z2 must be slowed down External fault clearing Z3 and Z2 race to drop out, if Z3 drops out first Z2 overtrips Z3 operates faster and drops slower Channel reset time helps Slower transmitter key dropout time helps

30 Directional Comparison Blocking Complications and Concerns External fault clearing failure Local backup provided by time-delayed Z3 or external BF relay clears the near bus Remote backup provided by Z2 clears the line Stop preference over start

31 Directional Comparison Blocking Complications and Concerns Current reversal Reach Margin Z3 reaches farther back than remote Z2 by at least 50% of Z2 overreach

32 Directional Comparison Unblocking Essentially the same as POTT Requires FSK In-section fault may impede communication In case of channel loss, a 150 ms window is open when permissive signal is bypassed and Z2 allowed to trip high speed

33 Direct Underreaching TT Underreaching Z1 elements send direct transfer trip Noisy channel can cause false trip Very secure channel required

34 Pilotless Accelerated Trip Schemes Communication equipment not justifiable in lower voltage transmission applications In-section faults may be uniquely determined by system conditions Detecting these conditions is all that is needed for high speed tripping

35 Pilotless Accelerated Trip Schemes Faulted System with Breakers Closed After Breaker 2 opens the only current that can flow is the fault current

36 Pilotless Accelerated Trip Schemes Faulted System with Breaker 2 Open Tripping conditions: Three-phase load was present before the fault Three-phase current was lost Current above the threshold detected in at least one phase

37 Breaker Failure Relaying Minimize the damage when a breaker fails to clear a fault Trips all sources locally within the critical clearing time to maintain system stability

38 Breaker Failure Relaying Common Causes of Breaker Failure Main breaker poles failed to clear the fault due to inadequate insulating medium Open trip coil or trip coil circuit Loss of tripping dc Mechanical failure of the breaker trip mechanism

39 Breaker Failure Relaying Operating Philosophy Activated only when a trip signal is issued from protective relay If current is above threshold after a pre-set time period, breaker failure condition is declared

40 Breaker Failure Relaying Considerations Timer settings must take into account the clearing time of the slowest breaker and the reset time of the fault detector The effect of any opening resistors in the circuit breakers on the reset time of fault detector Substation bus configuration must be taken into account to trip minimum number of breakers In multi-breaker schemes, possible transfer trip to the remote end

41 Out-of-Step Detection and Blocking Causes of Out-of-Step Power swings result from faults, switching, or big changes in load or generation Magnitude of the swing depends on the system impedance change during such conditions Swings can be stable or unstable

42 Power Transfer Equation where:, sin δ P power transferred from the sending to the receiving end V V S R P= P = P = sending end voltage receiving end voltage δ angle by which V leads V S S R VV X total reactance between the sending and receiving end R S X R

43 Power Transfer Curves,

44 Electrical Quantities During Swing Apparent Impedance Trajectories

45 Electrical Quantities During Swing Apparent Impedance Trajectories Apparent impedance during power swings can enter into the reach of distance relays If the apparent impedance stays longer than the time delay in a given zone, that distance element will trip as for a fault To prevent such tripping, out-of-step blocking schemes are employed

46 Out-of-Step Blocking Distance Elements If the timer expires between the two zones, out-of-step condition is declared and selected distance elements are blocked

47 Synchronism Checking After clearing a fault, one end of the line will reclose to test the line If the test is good, the other end can be closed but only if voltages are close enough and there is a small phase angle difference If the conditions are not right, the system will undergo a mechanical and electrical shock with a possible unstable swing

48 Synchronism Checking Monitored Quantities Voltage magnitudes Phase angle difference Slip frequency

49 Synchronism Checking Synchronizer Window

50 Synchronism Checking Conditions Both voltage phasors are above 59V setting Phase angle difference is small The above conditions are maintained for a short time, ensuring that the slip frequency is small enough and measurements are valid

51 Synchronism Checking Relay Phasor difference setting 25DV = 59V sinθ Timer setting 2 θ 25T = 360 Δ f The measured phasor difference should be below the setting for the given time Different than a synchronizing relay

52 Questions?